US20120167577A1 - Gas turbine system and process - Google Patents
Gas turbine system and process Download PDFInfo
- Publication number
- US20120167577A1 US20120167577A1 US12/983,408 US98340811A US2012167577A1 US 20120167577 A1 US20120167577 A1 US 20120167577A1 US 98340811 A US98340811 A US 98340811A US 2012167577 A1 US2012167577 A1 US 2012167577A1
- Authority
- US
- United States
- Prior art keywords
- stream
- turbine
- component
- turbine component
- gas turbine
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
Images
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- F02C3/00—Gas-turbine plants characterised by the use of combustion products as the working fluid
- F02C3/20—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
- F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
- F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
- F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
- F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
- F01K23/10—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- F02C6/00—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas- turbine plants for special use
- F02C6/18—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas- turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- F02C7/00—Features, components parts, details or accessories, not provided for in, or of interest apart form groups F02C1/00 - F02C6/00; Air intakes for jet-propulsion plants
- F02C7/12—Cooling of plants
- F02C7/14—Cooling of plants of fluids in the plant, e.g. lubricant or fuel
- F02C7/141—Cooling of plants of fluids in the plant, e.g. lubricant or fuel of working fluid
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- F02C7/00—Features, components parts, details or accessories, not provided for in, or of interest apart form groups F02C1/00 - F02C6/00; Air intakes for jet-propulsion plants
- F02C7/12—Cooling of plants
- F02C7/16—Cooling of plants characterised by cooling medium
- F02C7/18—Cooling of plants characterised by cooling medium the medium being gaseous, e.g. air
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
- F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
- F05D2260/00—Function
- F05D2260/60—Fluid transfer
- F05D2260/61—Removal of CO2
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E20/00—Combustion technologies with mitigation potential
- Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
- Y02E20/18—Integrated gasification combined cycle [IGCC], e.g. combined with carbon capture and storage [CCS]
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E20/00—Combustion technologies with mitigation potential
- Y02E20/32—Direct CO2 mitigation
Definitions
- the present disclosure is directed to gas turbine systems and processes. More specifically, the present disclosure is directed to systems and methods using CO 2 for cooling turbine components.
- Carbon sequestration in power systems captures carbon dioxide from exhaust gases and stores it in the sequestration process. Capturing the carbon consumes substantial amounts of energy and reduces performance efficiency of known power systems.
- a closed-loop cooling arrangement within a gas turbine is cooled with a non-electrically conductive liquid.
- a pump circulates the liquid and heat transfer is enhanced by an orifice placed within the loop that reduces pressure.
- the known system suffers from the drawback of not being able to provide carbon capture with desirable efficiency.
- an open-loop cooling arrangement including nitrogen from an air separation unit is used.
- the system suffers from the drawback that it is only applicable for oxygen-based (gasifier) systems in integrated gasification combined cycle (IGCC) operations.
- IGCC integrated gasification combined cycle
- a gas turbine system includes a compressor component configured to compress fluid to form a compressed fluid stream, a combustor configured to receive at least a first portion of the compressed fluid stream and at least partially combust a syngas to form a combustor discharge stream, and a turbine component positioned to receive the combustor discharge stream and to form a turbine component stream. At least a second portion of the compressed fluid stream is directed to the turbine component stream.
- a cool CO 2 stream directed from a CO 2 capture system cools the turbine component stream. The cool CO 2 stream is heated by the turbine component stream to form at least a heated CO 2 stream. At least a portion of the heated CO 2 stream transfers heat to the compressed fluid stream from the compressor to the combustor.
- a gas turbine system includes a compressor component configured to compress fluid to form a compressed fluid stream, a combustor configured to receive at least a first portion of the compressed fluid stream and at least partially combust a syngas to form a combustor discharge stream, and a turbine component positioned to receive the combustor discharge stream and to form a turbine component stream. At least a second portion of the compressed fluid stream is directed to the turbine component stream.
- a cool nitrogen stream directed from a second system cools the turbine component stream. The cool nitrogen stream is heated by the turbine component stream to form at least a heated nitrogen stream. At least a portion of the heated nitrogen stream transfers heat to the compressed fluid stream from the compressor to the combustor.
- a process includes providing a CO 2 capture system comprising an absorber and a stripper for forming a cool CO 2 stream, directing the cool CO 2 stream to a turbine component, transferring heat from a turbine component stream in the turbine component to the cool CO 2 stream to form at least a heated CO 2 stream, and directing at least a portion of the heated CO 2 stream through a heat exchanger to the CO 2 capture system.
- FIG. 1 schematically shows an exemplary gas turbine system according to an embodiment of the disclosure.
- FIG. 2 schematically shows an exemplary CO 2 capture system with a simplified depiction of an exemplary gas turbine system according to an embodiment of the disclosure.
- FIG. 3 schematically shows an exemplary gas turbine system according to an embodiment of the disclosure.
- Embodiments of the present disclosure permit the disclosed systems and methods to be applied to simple and combined cycle IGCC operations, permit the disclosed systems and methods to incorporate CO 2 capture processes into IGCC operations, permit the disclosed systems and methods to incorporate other systems into IGCC operations, permit increased efficiency by decreasing the amount of fuel required for reaching a predetermined firing temperature, permit increased efficiency by increasing an exhaust temperature being directed to a heat recovery steam generator, and permit lower cost installation, operation, and maintenance.
- FIG. 1 shows an exemplary gas turbine system 100 .
- the system 100 includes a compressor component 102 , a combustor 106 , and a turbine component 114 .
- the compressor component 102 is configured to compress fluid (for example, air or another atmospheric gas) to form a compressed fluid stream 104 .
- the combustor 106 is configured to receive at least a first portion 108 of the compressed fluid stream 104 and at least partially combust a syngas 110 to form a combustor discharge stream 112 .
- the turbine component 114 is positioned to receive the combustor discharge stream 112 to form a turbine component stream 116 .
- a second portion 118 of the compressed fluid stream 104 is directed to cool the turbine component stream 116 .
- a cool CO 2 stream 120 directed from a CO 2 capture system 122 cools the turbine component stream 116 .
- the cool CO 2 stream 120 has a temperature of about 300° F. to about 600° F. or about 100° F. to about 400° F. lower in temperature than gas turbine compressor discharge air.
- the cool CO 2 stream 120 consists essentially of gaseous CO 2 .
- the cool CO 2 stream 120 includes CO 2 at a concentration greater than that of air.
- the cool CO 2 stream 120 is heated by the turbine component stream 116 to form at least a heated CO 2 stream 124 (for example, having a temperature above about 1000° F.). A portion or all of the heated CO 2 stream 124 transfers heat to the compressed fluid stream 108 .
- the cool CO 2 stream 120 is directed to the turbine component stream 116 without assistance of a pump.
- the gas turbine system 100 includes a heat exchanger 134 .
- the heat exchanger 134 is positioned to transfer heat from the heated CO 2 stream 124 to the first portion 108 of the compressed CO 2 stream 104 .
- multiple stages of the compressor component 102 and the turbine component 114 permit any suitable portions of the compressed fluid stream 104 and/or the cool CO 2 stream 120 to exchange heat with the turbine component stream 116 and/or the combustion discharge stream 112 at a plurality of pressure and/or temperature relationships.
- Any suitable number of stages may be included.
- eighteen compressor stages are included.
- the first compressor stage 136 is the ninth stage
- the second compressor stage 138 is the thirteenth stage
- the third compressor stage 140 is the eighteenth stage.
- One or more portions of the compressed fluid stream 104 may be directed from multiple compressor stages to the turbine component 114 thereby cooling the turbine component stream 116 .
- the third compressor stage 140 directs the second portion 118 of the compressed fluid stream 104 to a second turbine stage 142 in the turbine component 114 .
- the turbine component 114 includes a first turbine stage 144 and a second turbine stage 142 . In one embodiment, the turbine component 114 further includes a third turbine stage 146 . Any suitable number of turbine stages may be included. One or more turbine stages of the turbine component 114 is positioned to receive the combustor discharge stream 112 to form the turbine component stream 116 . The second portion 118 of the compressed fluid stream 104 directed to the turbine component 114 cools the turbine component stream 116 . In one embodiment, the second compressor stage 138 directs the second portion 118 of the compressed fluid stream 104 to the first turbine stage 144 , the second turbine stage 142 , the third turbine stage 146 , or combinations thereof.
- the turbine component stream 116 is further cooled by the cool CO 2 stream 120 in the first turbine stage 144 .
- the cool CO 2 stream 120 is directed to the first turbine stage 144 , heat is transferred from the turbine component stream 116 in the first turbine stage 144 to the cool CO 2 stream 120 to form at least the heated CO 2 stream 124 , and at least a portion of the heated CO 2 stream 124 is directed through the heat exchanger 134 to the CO 2 capture system 122 .
- the turbine component 114 is arranged and disposed to receive the combustion discharge stream 112 from the combustor 106 and the heat exchanger 134 is arranged and disposed to transfer heat from the heated CO 2 stream 124 to at least the portion 108 of the compressed fluid stream 104 directed to the combustor 106 .
- CO 2 is used for closed loop cooling of the turbine component 114 .
- a closed loop CO 2 stream includes the heated CO 2 stream 124 and the cool CO 2 stream 120 .
- the combustion discharge stream 112 is directed to the turbine component 114 to form the turbine component stream 116
- the turbine component stream 116 is cooled with a cooled portion 120 of a closed loop CO 2 stream thereby forming the heated portion 124 of the closed loop CO 2 stream
- the compressed fluid stream 104 is heated by the heated portion 124 of the closed loop CO 2 stream.
- a portion of the cooled portion 120 of the closed loop CO 2 stream is directed from the carbon capture system 122 and at least a portion of the heated portion 124 of the closed loop CO 2 stream is directed to the carbon capture system 122 .
- the gas turbine system 100 further includes a heat recovery steam generator 126 .
- the turbine component stream 116 is directed to the heat recovery steam generator 126 .
- a portion 150 or all of the heated CO 2 stream 120 is directed to the heat recovery steam generator 126 .
- a portion of an outlet stream 148 from the heat recovery steam generator 126 is directed to the CO 2 capture system 122 for CO 2 capture/sequestration.
- FIG. 2 shows a schematic view of an exemplary CO 2 capture system 122 with a simplified depiction of the gas turbine system 100 .
- the CO 2 capture system 122 can be any suitable CO 2 capture system.
- the CO 2 capture system 122 is a chemical absorption process.
- the CO 2 capture system 122 includes an absorber 202 for receiving flue gas from heat recovery steam generator 126 .
- the flue gas is filtered by a filtration device 204 , transfers heat through a heat exchanger 206 (for example, a cross heat exchanger), and travels into a stripper 208 .
- the stripper 208 separates CO 2 from other components of the flue gas (for example, NO x and SO X ).
- a portion of the flue gas containing CO 2 is condensed by a condenser 210 and directed to a reflux drum 212 as captured CO 2 .
- the captured CO 2 120 is in general directed to a separate multistage intercooled-compressor system (not shown) for sequestration. A portion of the captured CO 2 120 may be redirected to the stripper 208 by a reflux pump 214 .
- a reboiler 216 for separation and either processed by a reclaimer 218 to form a sludge 226 or directed through the heat exchanger 206 , a storage tank 220 , a booster pump 222 , and a lean amine cooler 224 prior to reentering the absorber 202 and being vented to a stack (not shown).
- FIG. 3 shows another exemplary gas turbine system 300 .
- the system 300 includes the compressor component 102 , the combustor 106 , and the turbine component 114 .
- the compressor component 102 is configured to compress fluid (for example, air or another atmospheric gas) to form the compressed fluid stream 104 .
- the combustor 106 is configured to receive at least the first portion 108 of the compressed fluid stream 104 and at least partially combust the syngas 110 to form the combustor discharge stream 112 .
- the turbine component 114 is positioned to receive the combustor discharge stream 112 to form the turbine component stream 116 .
- the second portion 118 of the compressed fluid stream 104 is directed to cool the turbine component stream 116 .
- a cool nitrogen stream 320 directed from an air separation unit 322 or other suitable process cools the turbine component stream 116 .
- the cool nitrogen stream 320 is heated by the turbine component stream 116 to form at least a heated nitrogen stream 324 (for example, having a temperature above about 1000° F.).
- a portion or all of the heated nitrogen stream 324 transfers heat to the compressed fluid stream 108 .
- the gas turbine system 100 includes a heat exchanger 134 .
- the heat exchanger 134 is positioned to transfer heat from the heated nitrogen stream 324 to the first portion 108 of the compressed fluid stream 104 .
- multiple stages of the compressor component 102 and the turbine component 114 permit any suitable portions of the compressed fluid stream 104 and/or the cool nitrogen stream 320 to exchange heat with the turbine component stream 116 and/or the combustion discharge stream 112 at a plurality of pressure and/or temperature relationships.
- the turbine component stream 116 is further cooled by the cool nitrogen stream 320 in the first turbine stage 144 .
- the cool nitrogen stream 320 is directed to the first turbine stage 144 , heat is transferred from the turbine component stream 116 in the first turbine stage 144 to the cool nitrogen stream 320 to form at least the heated nitrogen stream 324 , and at least a portion of the heated nitrogen stream 324 is directed through the heat exchanger 134 to the heat recovery steam generator 126 .
- the first turbine stage 144 is arranged and disposed to receive the combustion discharge stream 112 from the combustor 106 and the heat exchanger 134 is arranged and disposed to transfer heat from the heated nitrogen stream 324 to at least the portion 108 of the compressed fluid stream 104 directed to the combustor 106 .
Abstract
A gas turbine system and process include a compressor component configured to compress fluid to form a compressed fluid stream, a combustor configured to receive at least a first portion of the compressed fluid stream and at least partially combust a syngas to form a combustor discharge stream, and a turbine component positioned to receive the combustor discharge stream and to form a turbine component stream. In the system and process, a cool stream directed from a second system cools the turbine component stream.
Description
- The present disclosure is directed to gas turbine systems and processes. More specifically, the present disclosure is directed to systems and methods using CO2 for cooling turbine components.
- In power generation systems, operational efficiencies are desired for meeting increased energy demand at lower costs. Carbon sequestration in power systems captures carbon dioxide from exhaust gases and stores it in the sequestration process. Capturing the carbon consumes substantial amounts of energy and reduces performance efficiency of known power systems.
- In a known power generation system, a closed-loop cooling arrangement within a gas turbine is cooled with a non-electrically conductive liquid. A pump circulates the liquid and heat transfer is enhanced by an orifice placed within the loop that reduces pressure. The known system suffers from the drawback of not being able to provide carbon capture with desirable efficiency.
- In another known power generation system, an open-loop cooling arrangement including nitrogen from an air separation unit is used. The system suffers from the drawback that it is only applicable for oxygen-based (gasifier) systems in integrated gasification combined cycle (IGCC) operations.
- A gas turbine system and process that is more efficient and does not suffer from the drawbacks of the prior art would be desirable in the art.
- In one embodiment, a gas turbine system includes a compressor component configured to compress fluid to form a compressed fluid stream, a combustor configured to receive at least a first portion of the compressed fluid stream and at least partially combust a syngas to form a combustor discharge stream, and a turbine component positioned to receive the combustor discharge stream and to form a turbine component stream. At least a second portion of the compressed fluid stream is directed to the turbine component stream. A cool CO2 stream directed from a CO2 capture system cools the turbine component stream. The cool CO2 stream is heated by the turbine component stream to form at least a heated CO2 stream. At least a portion of the heated CO2 stream transfers heat to the compressed fluid stream from the compressor to the combustor.
- In one embodiment, a gas turbine system includes a compressor component configured to compress fluid to form a compressed fluid stream, a combustor configured to receive at least a first portion of the compressed fluid stream and at least partially combust a syngas to form a combustor discharge stream, and a turbine component positioned to receive the combustor discharge stream and to form a turbine component stream. At least a second portion of the compressed fluid stream is directed to the turbine component stream. A cool nitrogen stream directed from a second system cools the turbine component stream. The cool nitrogen stream is heated by the turbine component stream to form at least a heated nitrogen stream. At least a portion of the heated nitrogen stream transfers heat to the compressed fluid stream from the compressor to the combustor.
- In one embodiment, a process includes providing a CO2 capture system comprising an absorber and a stripper for forming a cool CO2 stream, directing the cool CO2 stream to a turbine component, transferring heat from a turbine component stream in the turbine component to the cool CO2 stream to form at least a heated CO2 stream, and directing at least a portion of the heated CO2 stream through a heat exchanger to the CO2 capture system.
- Other features and advantages of the present invention will be apparent from the following more detailed description of the preferred embodiment, taken in conjunction with the accompanying drawings which illustrate, by way of example, the principles of the invention.
-
FIG. 1 schematically shows an exemplary gas turbine system according to an embodiment of the disclosure. -
FIG. 2 schematically shows an exemplary CO2 capture system with a simplified depiction of an exemplary gas turbine system according to an embodiment of the disclosure. -
FIG. 3 schematically shows an exemplary gas turbine system according to an embodiment of the disclosure. - Wherever possible, the same reference numbers will be used throughout the drawings to represent the same parts.
- Provided is a gas turbine system and method that is more efficient and does not suffer from the drawbacks of the prior art. Embodiments of the present disclosure permit the disclosed systems and methods to be applied to simple and combined cycle IGCC operations, permit the disclosed systems and methods to incorporate CO2 capture processes into IGCC operations, permit the disclosed systems and methods to incorporate other systems into IGCC operations, permit increased efficiency by decreasing the amount of fuel required for reaching a predetermined firing temperature, permit increased efficiency by increasing an exhaust temperature being directed to a heat recovery steam generator, and permit lower cost installation, operation, and maintenance.
-
FIG. 1 shows an exemplarygas turbine system 100. Thesystem 100 includes acompressor component 102, acombustor 106, and aturbine component 114. Thecompressor component 102 is configured to compress fluid (for example, air or another atmospheric gas) to form acompressed fluid stream 104. Thecombustor 106 is configured to receive at least afirst portion 108 of thecompressed fluid stream 104 and at least partially combust asyngas 110 to form acombustor discharge stream 112. Theturbine component 114 is positioned to receive thecombustor discharge stream 112 to form aturbine component stream 116. Asecond portion 118 of thecompressed fluid stream 104 is directed to cool theturbine component stream 116. - A cool CO2 stream 120 directed from a CO2 capture system 122 cools the
turbine component stream 116. The cool CO2 stream 120 has a temperature of about 300° F. to about 600° F. or about 100° F. to about 400° F. lower in temperature than gas turbine compressor discharge air. In one embodiment, the cool CO2 stream 120 consists essentially of gaseous CO2. In another embodiment, the cool CO2 stream 120 includes CO2 at a concentration greater than that of air. The cool CO2 stream 120 is heated by theturbine component stream 116 to form at least a heated CO2 stream 124 (for example, having a temperature above about 1000° F.). A portion or all of the heated CO2 stream 124 transfers heat to thecompressed fluid stream 108. In one embodiment, the cool CO2 stream 120 is directed to theturbine component stream 116 without assistance of a pump. - In one embodiment, the
gas turbine system 100 includes aheat exchanger 134. Theheat exchanger 134 is positioned to transfer heat from the heated CO2 stream 124 to thefirst portion 108 of the compressed CO2 stream 104. - As will be appreciated, multiple stages of the
compressor component 102 and theturbine component 114 permit any suitable portions of thecompressed fluid stream 104 and/or the cool CO2 stream 120 to exchange heat with theturbine component stream 116 and/or thecombustion discharge stream 112 at a plurality of pressure and/or temperature relationships. Any suitable number of stages may be included. For example, in one embodiment, eighteen compressor stages are included. In a further embodiment, thefirst compressor stage 136 is the ninth stage, thesecond compressor stage 138 is the thirteenth stage, and thethird compressor stage 140 is the eighteenth stage. One or more portions of thecompressed fluid stream 104 may be directed from multiple compressor stages to theturbine component 114 thereby cooling theturbine component stream 116. In one embodiment, thethird compressor stage 140 directs thesecond portion 118 of thecompressed fluid stream 104 to asecond turbine stage 142 in theturbine component 114. - The
turbine component 114 includes afirst turbine stage 144 and asecond turbine stage 142. In one embodiment, theturbine component 114 further includes athird turbine stage 146. Any suitable number of turbine stages may be included. One or more turbine stages of theturbine component 114 is positioned to receive thecombustor discharge stream 112 to form theturbine component stream 116. Thesecond portion 118 of thecompressed fluid stream 104 directed to theturbine component 114 cools theturbine component stream 116. In one embodiment, thesecond compressor stage 138 directs thesecond portion 118 of thecompressed fluid stream 104 to thefirst turbine stage 144, thesecond turbine stage 142, thethird turbine stage 146, or combinations thereof. - The
turbine component stream 116 is further cooled by the cool CO2 stream 120 in thefirst turbine stage 144. In one embodiment, the cool CO2 stream 120 is directed to thefirst turbine stage 144, heat is transferred from theturbine component stream 116 in thefirst turbine stage 144 to the cool CO2 stream 120 to form at least the heated CO2 stream 124, and at least a portion of the heated CO2 stream 124 is directed through theheat exchanger 134 to the CO2 capture system 122. In a further embodiment, theturbine component 114 is arranged and disposed to receive thecombustion discharge stream 112 from thecombustor 106 and theheat exchanger 134 is arranged and disposed to transfer heat from the heated CO2 stream 124 to at least theportion 108 of thecompressed fluid stream 104 directed to thecombustor 106. - In another embodiment, CO2 is used for closed loop cooling of the
turbine component 114. In this embodiment, a closed loop CO2 stream includes the heated CO2 stream 124 and the cool CO2 stream 120. For example, thecombustion discharge stream 112 is directed to theturbine component 114 to form theturbine component stream 116, theturbine component stream 116 is cooled with a cooledportion 120 of a closed loop CO2 stream thereby forming theheated portion 124 of the closed loop CO2 stream, and thecompressed fluid stream 104 is heated by theheated portion 124 of the closed loop CO2 stream. In a further embodiment, a portion of the cooledportion 120 of the closed loop CO2 stream is directed from thecarbon capture system 122 and at least a portion of theheated portion 124 of the closed loop CO2 stream is directed to thecarbon capture system 122. - In one embodiment, the
gas turbine system 100 further includes a heatrecovery steam generator 126. In this embodiment, theturbine component stream 116 is directed to the heatrecovery steam generator 126. In one embodiment, aportion 150 or all of the heated CO2 stream 120 is directed to the heatrecovery steam generator 126. A portion of anoutlet stream 148 from the heatrecovery steam generator 126 is directed to the CO2 capture system 122 for CO2 capture/sequestration. -
FIG. 2 shows a schematic view of an exemplary CO2 capture system 122 with a simplified depiction of thegas turbine system 100. The CO2 capture system 122 can be any suitable CO2 capture system. In one embodiment, the CO2 capture system 122 is a chemical absorption process. For example, in one embodiment, the CO2 capture system 122 includes anabsorber 202 for receiving flue gas from heatrecovery steam generator 126. The flue gas is filtered by afiltration device 204, transfers heat through a heat exchanger 206 (for example, a cross heat exchanger), and travels into astripper 208. Thestripper 208 separates CO2 from other components of the flue gas (for example, NOx and SOX). From thestripper 208, a portion of the flue gas containing CO2 is condensed by acondenser 210 and directed to areflux drum 212 as captured CO2. The capturedCO 2 120 is in general directed to a separate multistage intercooled-compressor system (not shown) for sequestration. A portion of the capturedCO 2 120 may be redirected to thestripper 208 by areflux pump 214. Other portions of the flue gas in thestripper 208 are directed to areboiler 216 for separation and either processed by areclaimer 218 to form asludge 226 or directed through theheat exchanger 206, astorage tank 220, abooster pump 222, and alean amine cooler 224 prior to reentering theabsorber 202 and being vented to a stack (not shown). -
FIG. 3 shows another exemplarygas turbine system 300. Thesystem 300 includes thecompressor component 102, thecombustor 106, and theturbine component 114. Thecompressor component 102 is configured to compress fluid (for example, air or another atmospheric gas) to form thecompressed fluid stream 104. Thecombustor 106 is configured to receive at least thefirst portion 108 of thecompressed fluid stream 104 and at least partially combust thesyngas 110 to form thecombustor discharge stream 112. Theturbine component 114 is positioned to receive thecombustor discharge stream 112 to form theturbine component stream 116. Thesecond portion 118 of thecompressed fluid stream 104 is directed to cool theturbine component stream 116. - A
cool nitrogen stream 320 directed from anair separation unit 322 or other suitable process cools theturbine component stream 116. Thecool nitrogen stream 320 is heated by theturbine component stream 116 to form at least a heated nitrogen stream 324 (for example, having a temperature above about 1000° F.). A portion or all of theheated nitrogen stream 324 transfers heat to thecompressed fluid stream 108. - In one embodiment, the
gas turbine system 100 includes aheat exchanger 134. Theheat exchanger 134 is positioned to transfer heat from theheated nitrogen stream 324 to thefirst portion 108 of thecompressed fluid stream 104. - As will be appreciated, multiple stages of the
compressor component 102 and theturbine component 114 permit any suitable portions of thecompressed fluid stream 104 and/or thecool nitrogen stream 320 to exchange heat with theturbine component stream 116 and/or thecombustion discharge stream 112 at a plurality of pressure and/or temperature relationships. - The
turbine component stream 116 is further cooled by thecool nitrogen stream 320 in thefirst turbine stage 144. In one embodiment, thecool nitrogen stream 320 is directed to thefirst turbine stage 144, heat is transferred from theturbine component stream 116 in thefirst turbine stage 144 to thecool nitrogen stream 320 to form at least theheated nitrogen stream 324, and at least a portion of theheated nitrogen stream 324 is directed through theheat exchanger 134 to the heatrecovery steam generator 126. In a further embodiment, thefirst turbine stage 144 is arranged and disposed to receive thecombustion discharge stream 112 from thecombustor 106 and theheat exchanger 134 is arranged and disposed to transfer heat from theheated nitrogen stream 324 to at least theportion 108 of thecompressed fluid stream 104 directed to thecombustor 106. - While only certain features and embodiments of the invention have been shown and described, many modifications and changes may occur to those skilled in the art (for example, variations in sizes, dimensions, structures, shapes and proportions of the various elements, values of parameters (for example, temperatures, pressures, etc.), mounting arrangements, use of materials, colors, orientations, etc.) without materially departing from the novel teachings and advantages of the subject matter recited in the claims. The order or sequence of any process or method steps may be varied or re-sequenced according to alternative embodiments. It is, therefore, to be understood that the appended claims are intended to cover all such modifications and changes as fall within the true spirit of the invention. Furthermore, in an effort to provide a concise description of the exemplary embodiments, all features of an actual implementation may not have been described (i.e., those unrelated to the presently contemplated best mode of carrying out the invention, or those unrelated to enabling the claimed invention). It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation specific decisions may be made. Such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure, without undue experimentation.
Claims (20)
1. A gas turbine system, comprising:
a compressor component configured to compress fluid to form a compressed fluid stream;
a combustor configured to receive at least a first portion of the compressed fluid stream and at least partially combust a syngas to form a combustor discharge stream; and
a turbine component positioned to receive the combustor discharge stream and to form a turbine component stream;
wherein at least a second portion of the compressed fluid stream is directed to the turbine component stream, a cool CO2 stream directed from a CO2 capture system cools the turbine component stream, the cool CO2 stream is heated by the turbine component stream to form at least a heated CO2 stream, and at least a portion of the heated CO2 stream transfers heat to the compressed fluid stream directed from the compressor to the combustor.
2. The gas turbine system of claim 1 , further comprising a heat recovery steam generator, wherein the turbine component stream is directed to the heat recovery steam generator.
3. The gas turbine system of claim 2 , wherein at least a second portion of the heated CO2 stream is directed to the heat recovery steam generator.
4. The gas turbine system of claim 3 , wherein at least a portion of an outlet stream from the heat recovery steam generator is directed to the CO2 capture system.
5. The gas turbine system of claim 1 , further comprising a heat exchanger, the heat exchanger positioned to transfer heat from the heated CO2 stream to the first portion of the compressed air stream.
6. The gas turbine system of claim 1 , further comprising the CO2 capture system.
7. The gas turbine system of claim 1 , wherein the compressor component comprises eighteen compressor stages.
8. The gas turbine system of claim 7 , wherein an eighteenth compressor stage directs the second portion of the compressed fluid stream to a second turbine stage of the turbine component.
9. The gas turbine system of claim 7 , wherein a ninth compressor stage and a thirteenth compressor stage direct the second portion of the compressed fluid stream to a first turbine stage of the turbine component, a second turbine stage of the turbine component, and a third turbine stage of the turbine component.
10. The gas turbine system of claim 1 , wherein the turbine component comprises a first turbine stage and a second turbine stage.
11. The gas turbine system of claim 10 , wherein the turbine component further comprises a third turbine stage.
12. The gas turbine system of claim 11 , wherein the turbine component stream is cooled by the cool CO2 stream for the second turbine stage and the third turbine stage.
13. The gas turbine system of claim 11 , wherein the compressor component comprises a first compressor stage, a second compressor stage, and a third compressor stage.
14. The gas turbine system of claim 1 , wherein the CO2 capture system comprises an absorber and a stripper for forming the cool CO2 stream.
15. A gas turbine system, comprising:
a compressor component configured to compress fluid to form a compressed fluid stream;
a combustor configured to receive at least a first portion of the compressed fluid stream and at least partially combust a syngas to form a combustor discharge stream; and
a turbine component positioned to receive the combustor discharge stream and to form a turbine component stream;
wherein at least a second portion of the compressed fluid stream is directed to the turbine component stream, a cool nitrogen stream directed from a second system cools the turbine component stream, the cool nitrogen stream is heated by the turbine component stream to form at least a heated nitrogen stream, and at least a portion of the heated nitrogen stream transfers heat to the compressed fluid stream from the compressor to the combustor.
16. The gas turbine system of claim 15 , wherein the second system is an air separation unit.
17. The gas turbine system of claim 15 , further comprising a heat recovery steam generator, wherein the turbine component stream is directed to the heat recovery steam generator.
18. The gas turbine system of claim 17 , wherein at least a second portion of the heated nitrogen stream is directed to the heat recovery steam generator.
19. A process, comprising:
providing a CO2 capture system, the CO2 capture system comprising an absorber and a stripper for forming a cool CO2 stream;
directing the cool CO2 stream to a turbine component;
transferring heat from a turbine component stream in the turbine component to the cool CO2 stream to form at least a heated CO2 stream; and
directing at least a portion of the heated CO2 stream through a heat exchanger to the CO2 capture system.
20. The process of claim 19 , wherein the turbine component is arranged and disposed to receive a combustion discharge stream from a combustor and the heat exchanger is arranged and disposed to transfer heat from the heated CO2 stream to at least a portion of a compressed fluid stream directed to the combustor.
Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/983,408 US20120167577A1 (en) | 2011-01-03 | 2011-01-03 | Gas turbine system and process |
DE102011056945A DE102011056945A1 (en) | 2011-01-03 | 2011-12-22 | Gas turbine system and method |
JP2011282946A JP2012140951A (en) | 2011-01-03 | 2011-12-26 | Gas turbine system and process |
CN2011104628035A CN102588118A (en) | 2011-01-03 | 2011-12-31 | Gas turbine system and process |
FR1250029A FR2970042A1 (en) | 2011-01-03 | 2012-01-02 | GAS TURBINE SYSTEM AND METHOD FOR COOLING WITH CO2 |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/983,408 US20120167577A1 (en) | 2011-01-03 | 2011-01-03 | Gas turbine system and process |
Publications (1)
Publication Number | Publication Date |
---|---|
US20120167577A1 true US20120167577A1 (en) | 2012-07-05 |
Family
ID=46273423
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/983,408 Abandoned US20120167577A1 (en) | 2011-01-03 | 2011-01-03 | Gas turbine system and process |
Country Status (5)
Country | Link |
---|---|
US (1) | US20120167577A1 (en) |
JP (1) | JP2012140951A (en) |
CN (1) | CN102588118A (en) |
DE (1) | DE102011056945A1 (en) |
FR (1) | FR2970042A1 (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10280760B2 (en) | 2015-09-30 | 2019-05-07 | General Electric Company | Turbine engine assembly and method of assembling the same |
US20200140770A1 (en) * | 2018-11-02 | 2020-05-07 | China University Of Petroleum (East China) | Integrated coal gasification combined power generation process with zero carbon emission |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20240003276A1 (en) * | 2022-06-30 | 2024-01-04 | Saudi Arabian Oil Company | Emissions reduction from vehicles by consuming low carbon fuel blends and utilizing carbon capture using adsorbent material |
Family Cites Families (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6487863B1 (en) * | 2001-03-30 | 2002-12-03 | Siemens Westinghouse Power Corporation | Method and apparatus for cooling high temperature components in a gas turbine |
JP2004211654A (en) * | 2003-01-08 | 2004-07-29 | Mitsubishi Heavy Ind Ltd | Gas turbine plant and combined plant |
US7581401B2 (en) * | 2005-09-15 | 2009-09-01 | General Electric Company | Methods and apparatus for cooling gas turbine engine components |
US8631639B2 (en) * | 2009-03-30 | 2014-01-21 | General Electric Company | System and method of cooling turbine airfoils with sequestered carbon dioxide |
US8267639B2 (en) * | 2009-03-31 | 2012-09-18 | General Electric Company | Systems and methods for providing compressor extraction cooling |
-
2011
- 2011-01-03 US US12/983,408 patent/US20120167577A1/en not_active Abandoned
- 2011-12-22 DE DE102011056945A patent/DE102011056945A1/en not_active Withdrawn
- 2011-12-26 JP JP2011282946A patent/JP2012140951A/en active Pending
- 2011-12-31 CN CN2011104628035A patent/CN102588118A/en active Pending
-
2012
- 2012-01-02 FR FR1250029A patent/FR2970042A1/en not_active Withdrawn
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10280760B2 (en) | 2015-09-30 | 2019-05-07 | General Electric Company | Turbine engine assembly and method of assembling the same |
US20200140770A1 (en) * | 2018-11-02 | 2020-05-07 | China University Of Petroleum (East China) | Integrated coal gasification combined power generation process with zero carbon emission |
US10899982B2 (en) * | 2018-11-02 | 2021-01-26 | China University Of Petroleum (East China) | Integrated coal gasification combined power generation process with zero carbon emission |
Also Published As
Publication number | Publication date |
---|---|
FR2970042A1 (en) | 2012-07-06 |
JP2012140951A (en) | 2012-07-26 |
DE102011056945A1 (en) | 2012-07-05 |
CN102588118A (en) | 2012-07-18 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
CN108136321B (en) | For CO2Method and apparatus for trapping | |
RU2315186C2 (en) | Low contamination thermal power station | |
EP2089139B1 (en) | Improved absorbent regeneration | |
CN101553645A (en) | Method of and apparatus for CO2 capture in oxy-combustion | |
US20120023947A1 (en) | Systems and methods for co2 capture | |
US20140208782A1 (en) | System and method for waste heat utilization in carbon dioxide capture systems in power plants | |
CN103096999A (en) | Jet engine with carbon capture | |
US20120023892A1 (en) | Systems and methods for co2 capture | |
EP2668994A1 (en) | Integrated CO2 phase changing absorbent for CO2 separation system | |
EP2974780A1 (en) | Energy recovery for waste gas capture systems | |
US10569215B2 (en) | Systems and methods for reducing the energy requirements of a carbon dioxide capture plant | |
US20120167577A1 (en) | Gas turbine system and process | |
EP2508721B1 (en) | Integrated gasification combined cycle system with vapor absorption chilling | |
US20140020388A1 (en) | System for improved carbon dioxide capture and method thereof | |
US20210069632A1 (en) | System and method of recovering carbon dioxide from an exhaust gas stream | |
US20170368499A1 (en) | System and method of recovering carbon dioxide from an exhaust gas stream | |
US20130036723A1 (en) | Oxy-combustion gas turbine hybrid | |
US11224837B2 (en) | Post-combustion carbon dioxide capture and compression | |
EP2529825B1 (en) | CO2 capture with carbonate looping | |
AU2013372962B2 (en) | Systems and methods for reducing the energy requirements of a carbon dioxide capture plant | |
EP2877258B1 (en) | Steam efficiency with non depletive condensing and adiabatic solvent heating | |
WO2024025544A1 (en) | Power plant with exhaust gas recirculation compressor | |
NO20210813A1 (en) | Method and plant for CO2 capture | |
AU2022231924A1 (en) | Chilled ammonia-based carbon dioxide abatement system with stacked sections | |
WO2024081169A1 (en) | High efficiency low energy consumption post combustion co2 capture process |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: GENERAL ELECTRIC COMPANY, NEW YORK Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:SAHA, RAJARSHI;PEMMI, BHASKAR;SHARMA, ANIL KUMAR;AND OTHERS;REEL/FRAME:025572/0326 Effective date: 20101119 |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |